EP3830386B1 - Outil de fond - Google Patents

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Publication number
EP3830386B1
EP3830386B1 EP19758449.3A EP19758449A EP3830386B1 EP 3830386 B1 EP3830386 B1 EP 3830386B1 EP 19758449 A EP19758449 A EP 19758449A EP 3830386 B1 EP3830386 B1 EP 3830386B1
Authority
EP
European Patent Office
Prior art keywords
tool
fluid pressure
downhole tool
fluid
flow area
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP19758449.3A
Other languages
German (de)
English (en)
Other versions
EP3830386A1 (fr
Inventor
Michael Wardley
George Telfer
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Ardyne Holdings Ltd
Original Assignee
Ardyne Holdings Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
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Publication of EP3830386A1 publication Critical patent/EP3830386A1/fr
Application granted granted Critical
Publication of EP3830386B1 publication Critical patent/EP3830386B1/fr
Active legal-status Critical Current
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/14—Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B29/00—Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windows; Deforming of pipes in boreholes or wells; Reconditioning of well casings while in the ground
    • E21B29/002—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe
    • E21B29/005—Cutting, e.g. milling, a pipe with a cutter rotating along the circumference of the pipe with a radially-expansible cutter rotating inside the pipe, e.g. for cutting an annular window
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/06—Sleeve valves

Definitions

  • the present invention relates to apparatus and methods for operating downhole tools and in particular, though not exclusively, to a valve which facilitates selective operation of a fluid pressure actuated tool when run on a tool string with other fluid pressure activated tools.
  • the tool comprises a gripping mechanism and a cutting mechanism both are fluid activated with the gripping mechanism first being set to anchor slips to the casing and on additional fluid pressure the cutting blades radially expand to contact the casing.
  • the drill string is rotated from surface to achieve a cutting action, there being a bearing inside the gripping mechanism to allow through rotation of the string past the slips.
  • This casing cutting and pulling tool is limited to procedures in which the drill string can be rotated. In circumstances such as when retrieving a seal assembly this is not possible as rotation of the string may disengage the seal assembly from its running tool.
  • WO 2016/172736 shows an injection valve having a valve main portion with an inlet and an outlet.
  • a flapper valve element is pivotally mounted in a lower portion of the valve main portion.
  • An axially movable variable orifice insert is positioned within the valve main portion including a second valve and a lower sleeve.
  • a pair of magnets of opposite polarity is included in which one of magnet is fixed within the valve main portion and the other of magnets is movable with the lower sleeve.
  • US 2016/305228 and US 2015/300124 both provide downhole tools with mechanisms useful for understanding the invention. It is therefore an object of the present invention to provide a downhole tool which allows selective operation of a second fluid pressure activated tool arranged on a tool string below a first fluid pressure activated tool.
  • a downhole tool comprising:
  • pressure activated tools located above the downhole tool can be operated until there is sufficient pressure applied to the piston sleeve for it to be pulled free of the magnet. Once pulled off the magnet, the piston sleeve can move to the second position thereby allowing sufficient fluid flow through the downhole tool to actuate pressure activated tools below the downhole tool.
  • the downhole tool may be considered as a valve.
  • the magnet is a permanent magnet.
  • the magnet is preferably mounted on the cylindrical body. In this way, the tool is simply constructed with only mechanical parts and solenoids or other arrangements using varying magnetic fields which would require power and/or connections to surface are not needed.
  • the piston sleeve is biased towards the first position by a spring.
  • the spring can be used to return the downhole tool to the first position if fluid flow is stopped to reduce fluid pressure through the tool.
  • the downhole tool can therefore be cycled between the first and second positions by varying fluid pressure within the tool. This makes the downhole tool resettable.
  • the pull strength of the magnet (how much weight in kg the magnet can hold) and the first flow area are selected to determine a cracking pressure for the downhole tool, the downhole tool moving from the first position to the second position when the cracking pressure is exceeded.
  • fluid pressure activated tools can be operated above the downhole tool with activation pressures below the cracking pressure.
  • the force holding the piston sleeve to the magnet decreases as soon as the cracking pressure is applied and the sleeve moves away from the magnet. If a spring were used this force increases as the two surfaces are separated. Accordingly, with magnets it is possible to 'switch' from a high closing force to a low closing force.
  • the pull strength of the magnet is greater than the force of the spring.
  • the spring is a weak spring and used only to return the piston sleeve to the first position and has no influence on the cracking pressure.
  • the second flow area is at least ten times greater than the first flow area.
  • the first flow area is greater than zero. In this way, the downhole tool does not prevent fluid flow in the first position. This advantageously removes the requirement to provide a seal in the flow path. The downhole tool has therefore less wear.
  • the downhole tool includes a check valve, wherein the check valve allows fluid flow though the tool in a direction opposite to the direction of movement of the piston sleeve between the first and second positions. In this way, the downhole tool can be run-in a well in the first position with the check valve allowing the drill string to fill above the tool.
  • the j-slot is continuous providing a plurality of first and second pin locations adjacent each other with at least one third pin location, the third pin location providing a third position for the piston sleeve which locks the sleeve in a position in which fluid flow is through the second flow area.
  • the tool can be fixed to provide the larger flow area so that the tool can be pulled from the well and allow the fluid in the string above the tool to drain through the tool.
  • the downhole tool includes a first fluid pressure activated tool which activates at a first fluid pressure level and a second fluid pressure activated tool which activates at a second fluid pressure level, the downhole tool being located between the first fluid pressure activated tool and the second fluid pressure activated tool and wherein the first fluid pressure level is lower than a fluid pressure required to overcome a pull strength of the magnet.
  • a method of selectively operating a second fluid pressure activated tool located below a first fluid pressure activated tool in a tool string comprising the steps:
  • the second fluid pressure activated tool is prevented from operating until a fluid pressure is applied which is sufficient to overcome the pull strength of the magnet.
  • the fluid pressure is kept below this predetermined pressure, the cracking pressure, the second fluid pressure activated tool will not operate.
  • the first pressure level may be greater than or equal to the second pressure level.
  • the second pressure level may be greater than or equal to the first pressure level.
  • the method includes the step of stopping fluid flow through the tool string and resetting the downhole tool to the first position. This allows multiple activation of tools on the tool string.
  • the method includes opening a check valve in the downhole tool at step (b) to allow the tool string to fill above the downhole tool through the check valve. This prevents the string requiring to fill through the first flow area.
  • the method includes the step of cycling the downhole tool between the first and second positions. More preferably, the method may include the steps of cycling the tool into a third position in which the downhole tool is locked to provide fluid flow through the downhole tool through the second flow area and pulling the tool string out of the well. This allows fluid in the tool string to drain through the downhole tool more quickly.
  • FIG. 1A of the drawings there is illustrated a downhole tool, generally indicated by reference numeral 10, including a piston sleeve 12 moveable in a cylindrical body 14 according to an embodiment of the present invention.
  • Cylindrical body 14 is of two-part construction to allow the piston sleeve 12 to be held within its central bore 16. At a first end 18 of the body 14 there is a pin section 20 and at an opposing second end 22 there is a corresponding box section 24 for connecting the tool 12 in a tool, work or drill string as is known in the art.
  • the body 14 has an inner surface 26 from which extend first 28 and second 30 opposing shoulders providing a pocket 32.
  • First shoulder 28 has lip 34 extending from an outer edge 36 which partially covers the pocket 32 to give an annular recess 38 towards the end 22.
  • the lip 34 is parallel to the central bore 16 and provides a wall 40 with an inner cylindrical surface 42.
  • the piston sleeve 12 is also substantially cylindrical in shape with a central cylindrical wall 44. At an end 46 of the cylindrical wall 44, there is an annular plate 48 extending perpendicularly from an outer surface 50 of the wall 44. The plate 48 provides a further lip 52 directed towards the second end 22 at a distal edge 54. In a first position, as illustrated in Figure 1A , the annular plate 48 and the end 46 of the wall 44 sit within recess 38. An inner surface 82 of the cylindrical wall 44 meets the inner surface 58 of wall 40 on the body 14. The upper surface 56 of plate 48 is held to a face 62 of a magnet 60 embedded in the first shoulder 28. The further lip 52 also locates in a rim 64 on the shoulder 28 at the inner surface 26 of the body 14. Magnet 60 is preferably a collection of magnets 60a-d arranged on and around the shoulder 28. In the first position the magnet 60 is entirely enclosed by the body 14 and the piston sleeve 12.
  • a dividing wall 66 which extends across the pocket 32 to reach the inner surface 26 of the body 14.
  • the dividing wall 66 may also be considered as an annular plate.
  • the dividing wall 66 creates a first chamber 70 bounded by the inner surface 26, dividing wall 66, outer surface 50 and annular plate 48.
  • the first chamber 70 has a fixed annular volume.
  • the second chamber contains a biasing element which is shown as a spring 74.
  • the second chamber 72 has a variable volume by virtue of the cylindrical wall 44 sitting inside the second shoulder 30, so that it can travel along the central bore 16 until its lower edge 76 meets a third shoulder 78 on the body 14 which is directed towards the second end 22.
  • Nipple 80 provides a cylindrical element 84 with an outer surface 86 which is parallel to and faces the inner surface 82.
  • the cylindrical element 84 has a conical end 88 directed towards the second end 22 of the tool 10.
  • inlet ports 90 located through the cylindrical wall 44. Typically, there will be four inlet ports 90 spaced equidistantly around the cylindrical wall 44. The inlet ports 90 provide access to the first chamber 70.
  • outlet ports 92 located through the cylindrical wall 44. Typically, there will be four outlet ports 92 spaced equidistantly around the cylindrical wall 44.
  • the outlet ports 92 are arranged at an angle to the central bore 16 so that they access the first chamber 70 near the dividing wall 66.
  • the inlet ports 90 have a larger combined cross-sectional flow area than that of the outlet ports 92.
  • a portion of the wall 40 lies between the inner surface 82 of the cylindrical wall 44 and the outer surface 86 on the cylindrical element 84, while not sitting over the inlet ports 90.
  • the diameter of the wall 40 on its inner surface 94 is greater than the diameter of the outer surface 86 of the cylindrical element 84.
  • This provides an annular gap 96 between the body 14 and the piston sleeve 12.
  • the cross-sectional flow area of the annular gap 96 is small compared to the combined cross-sectional flow area of the outlet ports 92.
  • the cross-sectional flow area of the annular gap 96 may be at least ten times smaller than the combined cross-sectional flow area of the outlet ports 92.
  • the cross-sectional flow area of the annular gap 96 is 0.04 square inches; the combined cross-sectional flow area of the outlet ports 92 is 0.70 square inches; and, the cross-sectional of the flow area of the central bore at its narrowest point at the wall 40 is 1.54 square inches.
  • the magnet(s) 60 have a pull strength of around 1000 lbs (454 Kg).
  • the spring 74 has an expanded support weight of around 500 lbs (227 Kg) with a compressed support weight of about 1000 lbs (454 Kg).
  • the downhole tool 10 is used in a well 100 as illustrated in Figure 2 , according to an embodiment of the present invention.
  • Well 10 is a conventional well as would be understood in the water, gas or oil mining industries.
  • the well 100 may be being formed by drilling, may be being completed for production, may be having an intervention operation performed or may be being abandoned.
  • the downhole tool 10 may be used in any process throughout the lifetime of a well 100.
  • the downhole tool 10 is located on a tool string 102, by connection via the box 24 and pin 20 sections, which is run from the surface 104 of the well 100.
  • the surface 104 can be on land or subsea and there will be associated equipment on the surface 104 (not shown) which will seal the well 100 and run the tool string 102 therefrom.
  • a first fluid pressure activated tool 106 Above the downhole tool 10 there is located a first fluid pressure activated tool 106.
  • second fluid pressure activated tool 108 is located above the downhole tool 10 .
  • Such fluid pressure activated tools are well known in the art.
  • Other tools may be arranged on the tool string as required.
  • the first and second fluid pressure activated tools 106,108 are run-in in an unactivated configuration.
  • the downhole tool 10 is run-in in the first position as shown in Figure 1A .
  • the piston sleeve 12 is held against the magnet 60 and the flow through the central bore 16 is limited as the flow has to pass through the small gap 96.
  • the magnet 60 is selected to have a pull strength greater than the activation fluid pressure of the first fluid pressure activated tool 106. In this way, the piston sleeve 12 is firmly held in place by the strong magnet 60. Using the magnet of the preferred embodiment it would take approx. 1000 lbs (454 Kg) of force to pull the piston sleeve 12 off the magnet 60.
  • the first fluid pressure activated tool 106 requires to be activated, fluid is pumped from surface 104 through the string 102. The pumping of very low volumes of fluid through the small gap 96 should be sufficient to activate the first fluid pressure activated tool 106.
  • An example may be a pump rate of 30 gpm (gallons per minute) (114 litres per minute) from surface being sufficient to activate a tool 106 above the downhole tool 10 with an activation pressure of, say, 500psi (3447 kPa).
  • the first fluid pressure activated tool 106 can be operated without fear that the second fluid pressure activated tool 108 will inadvertently activate.
  • the small flow rate permitted through the gap 96 causes a significant pressure drop through the tool 10 such that there is no fluid pressure increase below the tool 10 to operate the second fluid pressure activated tool 108.
  • the gap 96 disappears and fluid can flow directly from the central bore 16 through the inlet ports 90 to the first chamber 70. Fluid exits the chamber 70 through the outlet ports 92 with a much higher flow rate, in our example e.g. 250 gpm (946 l/min), due to the increased cross-sectional flow area in the fluid flow path. This higher flow rate through the central bore 16 below the tool 10, provides sufficient pressure to activate the second fluid pressure activated tool 108.
  • the tool 10 will now be in a second position as shown in Figure 1B .
  • the piston sleeve 12 has moved towards the first end 18, the magnet 60 and the plate 48 have separated and a larger flow path is formed around the nipple 80 via the inlet ports 90, first chamber 70 and outlet ports 92.
  • the magnet 60 is a permanent magnet as is known in the art. It has a north and south pole and can be orientated to attract the metal material of the piston sleeve 12. It will be appreciated that the magnet 60 may be a plurality of magnets, the magnets may be located on the piston sleeve 12 rather than the body 14 or there may be magnets oppositely arranged on the piston sleeve 12 and the body 14. These permanent magnets 60 require no power supply or connection to surface which makes them easier to use than electrically powered magnets providing variable magnetic fields and those that are based on being operated by solenoids.
  • the spring 74 is a relatively weak spring in comparison to the pull strength of the magnet 60. This ensures that the piston sleeve 12 will move rapidly once the pull strength has been overcome. Equally it means that the second fluid pressure activated tool 108 can be activated at any desired pressure level which may be the same, lower or higher than the pressure activation level of the first fluid pressure activated tool 106.
  • the first additional feature of the tool 110 in Figure 3A is the change to the plate 81 and the nipple 80. These are removed and replaced with a check valve 99.
  • Check valve 99 has a substantially cylindrical body 97 including an upper wall 95 which now provides the outer surface 93 which forms the gap 196 with the inner surface 158 of wall 140.
  • the lower end 91 has a retainer 89 for a poppet 87 located on the central axis. Poppet 87 is biased by a spring 85 against the retainer 89, as shown in Figure 3A .
  • the check valve 99 With the piston sleeve 112 in the first position, the check valve 99 is closed when the tool 110 is assembled on the string. Thus fluid flow is limited to taking the flow path through the narrow gap 196 to pass through the tool 110.
  • a flow path 83 is now created around the poppet 87 which provides a greater cross-sectional flow area than the gap 196 and thus the fluid in the well can be transferred to a position above the tool 110 quickly as the tool 110 is run in the well.
  • the spring 85 will now bias the poppet 87 back against the retainer 89, so closing the check valve 99. Fluid pumped from surface must now pass through the annular gap 196 and the tool 110 will operate as described hereinbefore.
  • Dividing wall 166 now has an increased length to provide an outer surface 79 on which is machined a slot 77.
  • Slot 77 is a j-slot arrangement as is known in the art and part illustrated in Figure 4 .
  • a pin 75 is located through the body 114 to locate in the slot 77. On run-in the pin 75 will be at a first gully 73 on the slot 77.
  • the piston sleeve 112 When the tool 110 is moved to the second position the piston sleeve 112 will have moved downwards and the pin 75 will guide and rotate the sleeve 112 so that the pin 75 now rests in a second gully 71.
  • the tool 110 can be cycled between the first and second positions with the pin 75 moving around the sleeve 112 in the slot 77.
  • the tool When the tool 110 is to be removed, the tool is cycled until the pin 75 arrives in an extended gully 69. In this location the sleeve 112 is moved further downwards than the second position so that the inlet 190 and outlet 192 ports are clear of the nipple 80 or check valve 99. Gully 69 is shaped so as to prevent movement of the pin 75 out of the gully 69 so that the tool 110 is fixed i.e. effectively locked, in the second position. This ensures that the larger flow area is available for draining the string as the tool 110 is pulled from the well.
  • FIG. 5 there is illustrated four permanent magnets 160a-d arranged around the body 114 and embedded in the shoulder 128. While it is known that a disadvantage in using magnets is that they attract metallic debris and remove it from any fluid, so potentially blocking inlets 190 or filling the chamber 170, the tools 10, 110 have features to negate this.
  • the magnets 160 are entirely bounded by the shoulder 128, inner wall 140, plate 148 and further lip 152. This prevents debris being attracted to the magnet 160.
  • the plate 48 is used as a wall to separate the chamber 70 from the magnet 60 and it is spaced apart therefrom.
  • the principle advantage of the present invention is that it provides a downhole tool which allows the selective operation of a second fluid pressure activated tool below a first fluid pressure activated tool.
  • It is a still further advantage of the present invention is that it provides a downhole tool which allows the selective operation of a second fluid pressure activated tool below a first fluid pressure activated tool which itself is fluid pressure operated.

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Claims (14)

  1. Outil de fond de trou (10), comprenant :
    un corps sensiblement cylindrique (14) comportant un alésage central (16) et étant conçu pour se raccorder à un train d'outils (102) ;
    un manchon de piston (12) situé dans l'alésage, le manchon de piston étant mobile sous l'action de la pression de fluide dans l'alésage entre une première position fournissant une première zone d'écoulement à travers l'alésage et une deuxième position fournissant une seconde zone d'écoulement à travers l'alésage ;
    un aimant (60) destiné à maintenir le manchon de piston contre le corps cylindrique dans la première position ;
    un ressort (74) destiné à solliciter le manchon de piston en direction de la première position ;
    la seconde zone d'écoulement étant supérieure à la première zone d'écoulement :
    ladite première zone d'écoulement étant supérieure à zéro ;
    la force de traction de l'aimant et la première zone d'écoulement étant sélectionnées pour déterminer une pression de fissuration pour l'outil de fond de trou, l'outil de fond de trou se déplaçant de la première position à la seconde position lorsque la pression de fissuration est dépassée ; et
    ladite force de traction de l'aimant étant supérieure à la force du ressort.
  2. Outil de fond de trou selon la revendication 1, ledit aimant étant un aimant permanent.
  3. Outil de fond de trou selon la revendication 1 ou la revendication 2, une pluralité d'aimants étant agencés autour du corps d'outil.
  4. Outil de fond de trou selon l'une quelconque des revendications précédentes, ladite seconde zone d'écoulement étant au moins dix fois supérieure à la première zone d'écoulement.
  5. Outil de fond de trou selon l'une quelconque des revendications précédentes, ledit outil de fond de trou comprenant un clapet anti-retour (99), ledit clapet anti-retour permettant l'écoulement de fluide à travers l'outil dans un sens opposé au sens de déplacement du manchon de piston entre les première et deuxième positions.
  6. Outil de fond de trou selon l'une quelconque des revendications précédentes, un agencement de fente en j (77) et de broche (75) entre le manchon de piston et le corps d'outil ; et ladite fente en j étant continue fournissant une pluralité de premier et deuxième emplacements de broche adjacents l'un à l'autre avec au moins un troisième emplacement de broche, le troisième emplacement de broche fournissant une troisième position pour le manchon de piston qui verrouille le manchon dans une position dans laquelle l'écoulement de fluide passe par la seconde zone d'écoulement.
  7. Outil de fond de trou selon l'une quelconque des revendications précédentes, ledit outil de fond de trou comprenant un premier outil activé par pression de fluide (106) qui s'active à un premier niveau de pression de fluide et un second outil activé par pression de fluide (108) qui s'active à un second niveau de pression de fluide, ledit outil de fond de trou étant situé entre le premier outil activé par pression de fluide et le second outil activé par pression de fluide et ledit premier niveau de pression de fluide étant inférieur à la pression de fluide nécessaire pour surmonter la force de traction de l'aimant.
  8. Procédé de fonctionnement sélectif d'un second outil activé par pression de fluide (108) situé sous un premier outil activé par pression de fluide (106) dans un train d'outils, comprenant les étapes :
    (a) montage d'un outil de fond de trou (10) selon l'une quelconque des revendications 1 à 7 entre les premier et second outils activés par pression de fluide ;
    (b) passage du train d'outils (102) dans un puits avec le manchon de piston (12) dans la première position ;
    (c) augmentation de la pression de fluide à travers le train d'outils jusqu'à ce qu'elle atteigne un premier niveau de pression suffisant pour faire fonctionner le premier outil activé par pression de fluide et activer le premier outil activé par pression de fluide ;
    lors de la sélection pour faire fonctionner le second outil activé par pression de fluide :
    (d) augmentation supplémentaire de la pression de fluide à travers le train d'outils jusqu'à ce qu'elle atteigne le niveau de pression de fissuration suffisant pour surmonter la force de traction de l'aimant (60) et déplacement du manchon de piston vers la deuxième position ;
    (e) écoulement de fluide à travers la seconde zone d'écoulement de l'outil de fond de trou pour augmenter la pression de fluide au niveau du second outil activé par pression de fluide jusqu'à un second niveau de pression de fluide suffisant pour faire fonctionner le second outil activé par pression de fluide et activer le second outil activé par pression de fluide ;
    ledit niveau de pression de fissuration étant supérieur au premier niveau de pression.
  9. Procédé selon la revendication 8, ledit premier niveau de pression étant supérieur ou égal au second niveau de pression.
  10. Procédé selon la revendication 8, ledit second niveau de pression étant supérieur ou égal au premier niveau de pression.
  11. Procédé selon l'une quelconque des revendications 8 à 10, ledit procédé comprenant l'étape d'arrêt de l'écoulement de fluide à travers le train d'outils et de remise de l'outil de fond de trou dans la première position.
  12. Procédé selon l'une quelconque des revendications 8 à 11, ledit procédé comprenant l'ouverture d'un clapet anti-retour (99) dans l'outil de fond de trou à l'étape (b) pour permettre le remplissage du train d'outils au-dessus de l'outil de fond de trou par l'intermédiaire du clapet anti-retour.
  13. Procédé selon l'une quelconque des revendications 8 à 12, ledit procédé comprenant l'étape de mise en cycle de l'outil de fond de trou entre les première et deuxième positions.
  14. Procédé selon la revendication 13, ledit procédé comprenant les étapes de mise en cycle de l'outil dans une troisième position dans laquelle l'outil de fond de trou est verrouillé pour fournir un écoulement de fluide à travers l'outil de fond de trou à travers la seconde zone d'écoulement et de traction du train d'outils hors du puits.
EP19758449.3A 2018-08-01 2019-07-31 Outil de fond Active EP3830386B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB1812535.1A GB2576011B (en) 2018-08-01 2018-08-01 Downhole Tool
PCT/GB2019/052140 WO2020025950A1 (fr) 2018-08-01 2019-07-31 Outil de fond

Publications (2)

Publication Number Publication Date
EP3830386A1 EP3830386A1 (fr) 2021-06-09
EP3830386B1 true EP3830386B1 (fr) 2023-10-25

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EP19758449.3A Active EP3830386B1 (fr) 2018-08-01 2019-07-31 Outil de fond

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US (1) US11512560B2 (fr)
EP (1) EP3830386B1 (fr)
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NO345875B1 (en) * 2020-03-06 2021-09-20 Archer Oiltools As Rotating stinger valve for J-slot connector

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GB201002854D0 (en) * 2010-02-19 2010-04-07 Wavefront Reservoir Technologies Ltd Magnet - operated pulsing tool
US10018022B2 (en) * 2012-04-27 2018-07-10 Tejas Research & Engineering, Llc Method and apparatus for injecting fluid into spaced injection zones in an oil/gas well
BR112017023274B1 (pt) * 2015-04-27 2023-02-07 Tejas Research & Engineering, Llc Válvula de injeção
MX2017016567A (es) 2015-06-19 2018-11-09 Drlg Tools Llc Valvula de circulacion.
US20150300124A1 (en) * 2015-07-07 2015-10-22 Tejas Research & Engineering, Llc Surface Controlled Downhole Valve with Supplemental Spring Closing Force for Ultra Deep Wells
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GB201516452D0 (en) 2015-09-16 2015-10-28 Telfer George Downhole cutting and pulling tool and method of use
US10458203B2 (en) * 2016-04-12 2019-10-29 Tejas Research & Engineering, Llc Pressure cycle actuated injection valve

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GB201812535D0 (en) 2018-09-12
GB2576011A (en) 2020-02-05
WO2020025950A1 (fr) 2020-02-06
GB2576011B (en) 2021-02-17
EP3830386A1 (fr) 2021-06-09
US11512560B2 (en) 2022-11-29
US20210317723A1 (en) 2021-10-14

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